Integrated system for the extraction, incineration and monitoring of waste or vented gases

ABSTRACT

Systems and methods for the extraction, incineration and monitoring of methane gas extracted from a mine are described herein. In some embodiments, a system includes a transportation platform, a fluid machine coupled to the transportation platform, an incinerator, a vent assembly and a flow interface assembly. The fluid machine is configured to be coupled to a gas well, and to produce a gas flow from the gas well. The incinerator is configured to be fluidically coupled to the fluid machine, and is configured to combust at least a portion of the gas flow from the gas well. The vent assembly is configured to be fluidically coupled to the fluid machine. The flow interface assembly is coupled to the transportation platform and is configured to selectively place the fluid machine in fluid communication with any one of the incinerator and the vent assembly.

CROSS-REFERENCE TO RELATED APPLICATIONS

This application claims priority to U.S. Provisional Application Ser.No. 61/258,710 entitled “Integrated System for the Extraction,Incineration and Monitoring of Methane Gas Produced in a MiningOperation,” filed Nov. 6, 2009, which is incorporated herein byreference in its entirety.

BACKGROUND

The embodiments described herein are related generally to theextraction, incineration and monitoring of a waste or vented gas. Morespecifically the embodiments described herein relate to a mobile,integrated, self-powered system for extraction, incineration andmonitoring of methane gas extracted from gob wells in a miningoperation.

For some sub-surface or underground mines from which coal and other hardrock, metal and non-metal minerals such as, for example, trona, areextracted, the specific characteristics of the geological formation ofthe deposit and surrounding strata may result in the coexistence ofmethane gas (also referred to as mine methane). During the undergroundmineral extraction processes, in which a layer of the target coal andminerals is removed, a rubbelized (or fractured) zone forms, filling thevoid of the post mining area of the worked-out section of the mine. Thisrubbelized zone is created by the collapse and subsidence of theover-burdened strata surrounding the worked-out section of the mine, andis referred to as gob or goaf (also known as gob areas or goaf areas).These gob areas become temporary underground reservoirs that eventuallyoverflow and act as conduits through which the mine methane gas flowsinto the working areas of the mine.

Various regions (e.g., countries and states) have differing requirementsrelated to acceptable or allowable limits of methane concentration inthe working areas and/or sealed sections of the mine. Accordingly,underground mines employ ventilation systems to dilute methane to a safeconcentration for the mine environment. Additionally, some known mines,particularly those deemed to have high levels of flammable gas therein(i.e., high levels or concentrations of methane gas), employ post-miningdegasification measures known as gob wells to remove mine methane gasfrom the gob to prevent it from flowing into the working areas andexceeding allowable safe concentration limits.

Gob wells are wells or holes drilled or bored from the mine surface inadvance of mining operations. The wells typically terminate in the rockstrata above the mineral seam and are not usually operational prior tosubsidence (i.e., because the gob wells produce little to no methaneprior to subsidence). After mining operations pass the well, the strataabove the mined area collapses resulting in a gob within which methanegas is collected. An extraction device is connected to the well, whichis used to extract the methane released from the gob. Methane fromventilation or gob wells is typically vented from the mine to maintain asafe working environment for the miners.

In addition to being a serious safety hazard within the mine, methaneand other constituents within the vented gas can be potent greenhousegases that contribute to global warming. For example, methane gas has aGlobal Warming Potential (“GWP”) equivalent to 21 times that of carbondioxide. The GWP is an estimation of how much a gas is expected tocontribute to global warming, when compared to the harmful effects of anequivalent measure of carbon dioxide over the same period. Morespecifically, the GWP is an index representing the combined effect ofthe differing times greenhouse gases remain in the atmosphere and theirrelative effectiveness in absorbing outgoing infrared radiation.Consequently, when removing gases (e.g., methane, hydrocarbons and/orvolatile organic compounds) from a mine, it is undesirable to releasethe gases into the atmosphere. For example, as illustrated in FIG. 1, if1 unit of methane were combusted or oxidized, it would create combustionproducts including 2.75 units of carbon dioxide; however because methanehas a much higher GWP, a net benefit to the environment equivalent to18.25 units of carbon dioxide is realized. Accordingly, combusting themethane extracted from a mine can lower the overall GWP of a miningoperation. Similarly stated, combusting the extracted methane can resultin a reduction of greenhouse gas (“GHG”) emissions.

In some regions, such reduction in GHG emissions can be encouragedand/or mandated by regulations. Thus, in some regions, it can bedesirable not only to combust the extracted gas to reduce the GHGemissions, but also measure the reduction of GHG emissions to ensurecompliance with such regulations. Known systems for gas extraction,however, have primarily been used to extract and vent the gas foroperational and safety purposes, and have not included systems formeasuring the reduction in GHG emissions to meet such regulatory guidelines.

Additionally, in some regions, depending on the state of regulation,this reduction in global warming potential (or GHG emissions) can beused generate environmental attribute credits (e.g., carbon offsetcredits). These credits can be sold to other entities to offset theirown industrial pollution or the GWP of carbon emissions resulting fromtheir own operations. However, there are only a few countries thatactively use gob wells to degas mine methane gas, most notably theUnited States, which to date have not regulated greenhouse gasemissions. Thus, the technology deployed to date in the market place hasprimarily been used to extract and vent the gas for operational andsafety purposes. The emerging market for environmental attribute credits(e.g., carbon offset credits) and the potential for greenhouse gasregulations has created the potential demand for the combustion of thepreviously vented mine methane gas from the gob.

Although methane extraction and combustion systems for use in miningoperations are known, such known systems suffer several disadvantages.For example, known methane extraction and combustion systems aretypically fixed-location or fixed-position systems. Such known systemsare difficult to assemble, disassemble, and re-assemble, resulting insystems that are not easily or readily mobile. The non-mobile nature ofsuch systems is undesirable in many mining environments, such as, forexample, mining environments where gob wells have short operationallives (often less than nine months) and where new gob wells must befrequently drilled. Furthermore, the lack of mobility of known methaneextraction and combustion systems can compel construction of multiplesystems for each of a group of gob wells, which can add considerablecost to the mining operation.

Additionally, known methane extraction and combustion systems require anexternal power source to remove the methane, maintain the ignition ofthe combustion device and/or control the overall operation. For example,some known systems include extraction pumps that extract methane fromgob wells and route the methane via a piping system to a centrallylocated methane incinerator or flare. Such extraction pumps can bepowered by, for example, electrical power provided by a grid or agenerator co-located with the system (e.g., a generator system poweredby a diesel engine). Providing a constant, reliable power source to suchsystems can be difficult in the case of remotely located systems,because access to a grid may not be available or is expensive to supplyand it can be difficult to provide an adequate source of fuel to suchsystems.

Furthermore, known methane extraction and combustion systems typicallyfail to accurately measure the amount of methane extracted and combustedto calculate the reduction in GHG emissions and/or to generateenvironmental attribute credits (e.g., carbon offset credits).Regulations related to ensuring that the installation is in compliancewith regulatory guidelines and/or the generation and sales ofenvironmental attribute credits (e.g., carbon offset credits) mayrequire that the amount of methane extracted, combusted, and/or theresultant emissions of the combusted methane be accurately measured, andsome instances certified by an accredited third party auditor. Becauseknown systems fail to accurately measure and monitor the specific amountof methane gas that is actually destroyed, they are incapable ofproviding such certified measurements to the specifications andparameters necessary to ensure regulatory compliance and/or to generateenvironmental attribute credits (e.g., carbon offset credits). Thus, aneed exists for improved, mobile systems that integrate components foroff-grid extraction, combustion, measurement and monitoring of minemethane gas.

SUMMARY

Systems and methods for the extraction, incineration and monitoring ofmethane gas extracted from a mine are described herein. In someembodiments, a system includes a transportation platform, a fluidmachine coupled to the transportation platform, an incinerator, a ventassembly and a flow interface assembly. The fluid machine is configuredto be coupled to a gas well, such as, for example, a gob well, and toproduce a gas flow from the gas well. The incinerator is configured tobe fluidically coupled to the fluid machine, and is configured tocombust at least a portion of the gas flow from the gas well. The ventassembly is configured to be fluidically coupled to the fluid machine.The flow interface assembly is coupled to the transportation platformand is configured to selectively place the fluid machine in fluidcommunication with any one of the incinerator and the vent assembly.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 illustrates combustion of methane and the Global WarmingPotential benefit derived from this combustion.

FIG. 2 is a schematic block diagram of a mining environment including amobile methane extraction, incineration and monitoring system, accordingto an embodiment.

FIG. 3 is an illustration of a mining environment including a methaneextraction, incineration and monitoring system, according to anembodiment.

FIG. 4 is a schematic diagram of a gas extraction, incineration andmonitoring system, according to an embodiment.

FIG. 5 is a schematic diagram of a gas extraction, incineration andmonitoring system, according to an embodiment.

FIG. 6 is a schematic diagram of a gas extraction, incineration andmonitoring system, according to an embodiment.

FIG. 7 is a schematic illustration of a gas extraction, incineration andmonitoring system, according to an embodiment.

FIG. 8 is a system block diagram of a portion of the gas extraction,incineration and monitoring system shown in FIG. 7.

FIG. 9 is a schematic illustration of a control system of the gasextraction, incineration and monitoring system shown in FIG. 7.

FIG. 10 is a schematic illustration of a monitoring and measurementsystem of the gas extraction, incineration and monitoring system shownin FIG. 7.

FIG. 11 is a schematic illustration of a communications system of thegas extraction, incineration and monitoring system shown in FIG. 7.

FIG. 12 is a schematic illustration of a power transmission system ofthe gas extraction, incineration and monitoring system shown in FIG. 7.

FIG. 13 is a flow chart illustrating a method of operating a gasextraction, incineration and monitoring system, according to anembodiment.

FIG. 14 is a flow chart illustrating a method of operating a gasextraction, incineration and monitoring system, according to anembodiment.

FIG. 15 is a flow chart illustrating a method of operating a gasextraction, incineration and monitoring system, according to anembodiment.

FIG. 16 is a flow chart illustrating a method of operating a gasextraction, incineration and monitoring system, according to anembodiment.

FIG. 17 is a side view of a gas extraction, incineration and monitoringsystem in a first configuration, according to an embodiment.

FIG. 18 is a side view of the gas extraction, incineration andmonitoring system shown in FIG. 17, in a second configuration.

FIGS. 19 and 20 are perspective views of the gas extraction,incineration and monitoring system shown in FIG. 17, in the secondconfiguration.

DETAILED DESCRIPTION

The embodiments described herein are capable of extracting methane froma mining environment, incinerating (or combusting) the methane, andmonitoring the extraction, combustion, and resultant reduction ingreenhouse gas emissions. In some embodiments, the system can generate areport indicating compliance with regulations limiting greenhouse gasemissions. In other embodiments, the system can generate environmentalattribute credits (e.g., carbon offset credits) based on the reductionin greenhouse gas emissions resulting from the combustion of methane ascompared to the venting of the raw methane extracted from the miningenvironment. Additionally, one or more embodiments are also mobileand/or portable such that a methane extraction, incineration andmonitoring system can be moved or transported to different locations(e.g., different gas wells) in a mining environment. Furthermore, one ormore embodiments are capable of operating independently from an externalpower source (e.g., an electric power grid). Said another way, in someembodiments, the system is configured to power one or more extractionpumps with a portion of the gas extracted from a mining environment(which can include methane). In some embodiments, the disclosed systems,apparatus, and/or methods can produce self-sustaining, integrated,self-contained, and/or mobile devices suitable for use for destructionof flammable gasses being emitted to the atmosphere from undergroundvoid spaces such as operating mines, disused sections of worked outmines and sealed sections of mines, abandoned mines where gas is beingdesorbed from coal seams, sandstone or other porous geological strata.

In some embodiments, any of the systems described herein can be coupledto a gas well (e.g., a gob well or other extraction well associated witha mining operation, a landfill vent, a gas well associated with gasexploration or the like) by a gas well adapter that includes a frame, aninlet member, an outlet member and a valve. The inlet and outlet membersare each coupled to the frame, which can be, for example, a portableskid. The inlet member is configured to be coupled to a gas well. Theoutlet member is configured to be coupled to a receiver configured toreceive a gas flow from the gas well. The receiver can be, for example,any suitable reservoir, fluid machine or the like. The valve isconfigured to selectively place the inlet member in fluid communicationwith the outlet member. The outlet member is electrically isolated fromthe inlet member. In this manner, any electrical charge that may begenerated “upstream” of the outlet member (e.g., by a lightening strike,by a spark generated by an upstream portion of the system or the like)will be impeded from being conveyed into the gas well. In someembodiments, the gas well adapter can include an electrical isolationmember configured to electrically isolate the inlet member and theoutlet member.

In some embodiments, a system includes a transportation platform, afluid machine coupled to the transportation platform, an incinerator, avent assembly and a flow interface assembly. The fluid machine isconfigured to be coupled to a gas well (e.g., a gob well or otherextraction well associated with a mining operation, a landfill vent, agas well associated with gas exploration or the like), and to produce agas flow from the gas well. The incinerator is configured to befluidically coupled to the fluid machine, and is configured to combustat least a portion of the gas flow from the gas well. The vent assemblyis also configured to be fluidically coupled to the fluid machine. Theflow interface assembly is coupled to the transportation platform and isconfigured to selectively place the fluid machine in fluid communicationwith any one of the incinerator and the vent assembly. In someembodiments, the vent assembly is spaced apart from and/or is separatefrom the incinerator. In this manner, the portion of the gas flow thatis conveyed through the vent assembly does not also flow through theincinerator, and is therefore not considered in the determination of thereduction in greenhouse gas emissions.

In some embodiments, a system can be configured to be moved between afirst (or transportation) configuration and a second (or operational)configuration, thereby allowing the system to be moved from one locationto the next. In some embodiments, such systems can include atransportation platform, a fluid machine, an incinerator and a flowinterface assembly. The fluid machine is coupled to the transportationplatform. The fluid machine, which can be a pump, a blower or the like,is configured to be coupled to a gas well and to produce a gas flow fromthe gas well. The incinerator is movably coupled to the transportationplatform between a first position and a second position. A verticalheight of the incinerator and the transportation platform is within(i.e., is compliant with) a standard for on-road transportation when theincinerator is in the first position. The incinerator is configured tobe fluidically coupled to the fluid machine when the incinerator is inthe second position. The incinerator configured to combust at least aportion of the gas flow when the incinerator is in the second position.The flow interface assembly is coupled to the transportation platform,and is configured to selectively place the fluid machine in fluidcommunication with any one of the incinerator and a vent assembly.

FIG. 2 is a schematic block diagram of a mining environment M includinga methane extraction, incineration and monitoring system 100, accordingto an embodiment. Mining environment M includes the ground surface SU,the strata ST, the gob (indicated as GOB), a series of gob wells GW, amined area MA, and an unmined area UM. The strata ST is located abovemined area MA. The gob wells GW are drilled into strata ST, and areconfigured to convey methane from the gob.

The system 100 is a methane extraction, incineration and monitoringsystem described in more detail herein, which can be moved and/ortransported along surface SU to be operably coupled to any of the gobwells GW. As illustrated in FIG. 2, although the system 100 is shown asbeing located at one gob well GW, the system 100 can be moved from anygob well GW to one or more of the other gob wells GW to extract,incinerate and monitor methane extraction and incineration at one ormore of the gob wells GW. Thus, the system 100 can be mobile among gobwells in mining environment 100. For example, in some embodiments, allcomponents of the system 100 can be disposed on a portable structure,such as, for example, a transportation platform and/or a trailer, asdescribed in more detail herein. In other embodiments, a portion of thesystem 100 can be mounted on a portable structure (e.g., a skidconfigured to be moved by a fork lift). In other words, system 100 caninclude one or more structures or portions (e.g., equipment) that arecollectively or independently mobile. This arrangement facilitates themovement of system 100 between the gob wells GW, thereby allowing asingle system 100 to be used to extract methane from each gob well asthe mined area MA advances. For example, in some embodiments, the system100 can reside at and/or remain operational to extract methane from agob well GW for a period of anywhere from 3 months to 10 years. In someembodiments the system 100 can remain coupled to a particular gob wellfor less than 12 months.

FIG. 3 is an illustration of a mining environment including a methaneextraction, incineration and monitoring system, according to anembodiment. The mining environment of FIG. 3 includes a methaneextraction, incineration and monitoring system labeled “System,” aseries of gob wells, a gob region, caved in sections of a mine, a rockstrata and a series of coal seams. FIG. 3 also illustrates the surfacelandscape above the mining area. The methane extraction, incinerationand monitoring system can be moved along the surface to be operativelycoupled to the various gob wells of the mining environment to extractand incinerate methane, as described herein.

FIG. 4 is a schematic diagram of gas extraction, incineration andmonitoring system 200, according to an embodiment. System 200 includes agas extraction pump unit 231, a gas incinerator 253 (also referred to asa combustor, burner, and/or flare), measuring and monitoring equipment291, a communication system 292, a data storage and reporting system295, and a control system 297. The gas extraction pump 231 is coupled toa gas well on its inlet side and the gas incinerator on its outlet side,and is configured to produce a gas flow from the gas well. The gasextraction pump 231 can be any fluid machine suitable for producing apressurized fluid and/or fluid flow, such as, for example, a blower, apump or the like. The gas extraction pump 231 is operatively coupled toand driven by a power source 232. The power source 232 can be anysuitable power source for providing power to operate the gas extractionpump 231, provide power to the measuring and monitoring equipment, thecommunication system, and/or any other power consuming devices withinthe system 200. For example, as illustrated in FIG. 4, the power sourcecan be a power source that coverts a portion of the extracted gas (whichcan include, for example, methane or other flammable constituents) intopower. In this manner, system 200 can be operated independently from anexternal power source, such as, for example, an electrical power grid.In some embodiments, for example, the power source can be an internalcombustion engine configured to combust methane to produce power. Oneexample of such an engine is described in U.S. Pat. No. 6,578,559,entitled “Methane Gas Control System,” which is incorporated herein byreference in its entirety. Another example of such an engine isdescribed in U.S. Patent Publication No. 2008/0011248, entitled “Systemand Method for Control of a Gas,” which is incorporated herein byreference in its entirety. In yet other embodiments, the power sourcecan be a methane-powered turbine engine. In still other embodiments, thepower source can be a methane gas fuel cell.

In use, waste and/or vented gas can be extracted from the gas well bythe gas pump 231. A first portion of the extracted gas can be conveyedto the power source 232 as fuel for the power source 232, and a secondportion of the extracted gas can be conveyed to the gas incinerator 253to be incinerated to reduce the greenhouse gas emissions resulting fromthe extraction process. Additionally, under certain conditions, aportion of the extracted gas can be vented to atmosphere via a flow paththat excludes the gas incinerator 253. In this manner, the portion ofthe extracted gas that is vented is therefore not considered in anydetermination of the reduction in greenhouse gas emissions. A portion ofthe extracted gas can be vented to atmosphere, for example, duringpriming or startup of system 200 until, for example, a sufficient flowof gas is achieved from the gas well to support incineration of the gasand/or operation of the power source.

The measuring and monitoring equipment 291 can continuously monitor andmeasure parameters of system 200 to generate an output associated with areduction in greenhouse gas emissions resulting from the incineration ofthe extracted gas. In some embodiments, the measuring and monitoringequipment 291 can generate a report associated with the compliance ofthe site and/or facility with an applicable regulation (e.g., aregulation limiting GHG emissions). In other embodiments, for example,the measuring and monitoring equipment 291 can generate environmentalattribute credits (e.g., carbon offset credits), which can be traded ona suitable exchange, based on the quantity of gas extracted and oxidizedby the gas incinerator. For example, the measuring and monitoringequipment 291 can measure the combusted gas temperature, pressure,volumetric flow, and concentration of constituents within the gas (e.g.,methane) and/or the like. In some embodiments, the measuring andmonitoring equipment 291 can measure the mass of certain constituentswithin the gas (e.g., methane) delivered to the gas incinerator and theefficacy and/or efficiency of combustion of such constituents by the gasincinerator. In some embodiments, the measuring and monitoring equipment291 can monitor and/or measure other system and/or operationalparameters.

Accordingly, the measuring and monitoring equipment 291 is operativelycoupled to many of the other elements or components of system 200: thegas extraction pump 231; the gas incinerator 253; gas lines connectingthe gas extraction pump 231 to the gas well GW, and/or one or morevents; the control system 297 and the communication system 292. Forexample, the measuring and monitoring equipment 291 can be coupled tosensors that measure pressure, temperature, flow-rate, and/or gasconcentration at various locations within the gas lines of system 200 todetermine the amount of gas (e.g., methane, volatile organic compounds,GHG or the like) processed (e.g., extracted and/or incinerated) bysystem 200. The measuring and monitoring equipment 291 can be coupled toinfrared sensors, tunable diode laser sensors, optical sensors, thermalconductivity sensors, gas density sensors, gas chromatography sensors,and/or other sensors within the gas lines, the gas incinerator 253and/or any other portion of the system 200 to determine, for example,the concentration of constituents (e.g., methane) in the gas flow. Themeasuring and monitoring equipment 291 can also be coupled to sensorswithin and/or adjacent the gas incinerator to determine the combustioncharacteristics within the gas incinerator 253. Additionally, themeasuring and monitoring equipment 291 can be coupled to the gasextraction pump 231 to determine, for example, the efficiency of gasextraction pump.

The measuring and monitoring equipment 291, and any of the componentsand/or systems described herein having similar functionality (e.g., thecontrol assembly 590 described below), can include commerciallyavailable components used in the natural gas production, mining and/oremissions measurement industries to monitor gas production. In someembodiments, the measuring and monitoring equipment 291 can include aprogrammable logic controller (“PLC”) and/or another processor. In someembodiments, the measuring and monitoring system can beself-calibrating. In this manner, the measurement of the gas emissions,and therefore, the amount of gas incinerated can be accurately measuredby taking into account variables such as, for example, changing ambientconditions, changing constituency of the extracted gas and/or the like.

The measuring and monitoring equipment 291 is operatively coupled to thecommunication system 292 such that data or information generated by themeasuring and monitoring equipment can be transmitted to the datastorage and reporting system 295 and/or any other system configured toreceive such information. In some embodiments, the data or informationcan be stored locally (e.g., at system 200). The communication system292, and any of the components and/or systems described herein havingsimilar functionality (e.g., the control assembly 590 described below),can include commercially available components to perform the functionsdescribed herein. For example, the communication system 292 can includea wireless interface such as microwave, satellite, cellular,industrial/scientific/medical (“ISM”) band, licensed band, and/or otherradio devices. Alternatively (or complimentarily), the communicationsystem can include a wired interface such as an Ethernet local areanetwork (“LAN”) or wide area network (“WAN”).

As illustrated in FIG. 4, the data storage and reporting system 295 caninclude an interface complimentary to the interface of the communicationsystem 292 such that the data storage and reporting system can receivedata or information (e.g., data and information signals) produced by themeasuring and monitoring equipment 291 and transmitted via thecommunication system 292. In some embodiments, intermediatecommunication systems and/or communications networks can exist betweenthe communication system 292 and the data storage and reporting system295. For example, the communication system and/or any intermediatecommunication systems can include a cellular interface to a wirelesswide area network (“WWAN”) that is operatively coupled to the Internet,and the data storage and reporting system can be operatively coupled toan Ethernet LAN including a gateway to a fiber-optic connectionoperatively coupled to the Internet. Accordingly, the communicationsystem can be in communication with the data storage and reportingsystem via the WWAN, Internet, fiber-optic connection, and Ethernet LAN.

Furthermore, the communication system 292 can receive control and/orconfiguration information (e.g., control and/or configuration signals)from the control system 297, which can be (but is not necessarily)remotely located from the system 200. For example, the measuring andmonitoring equipment 291 can produce and/or convey signals to controlgas valves, flame ignition modules, shutdown and/or startup of gasextraction pump, data reporting schedules, and/or other operationalparameters or components of system 200, in response to informationreceived from the control system via the communications system.Embodiments including such control configurations and executing suchcontrol algorithms are further described herein (see e.g., the system500 shown and described below). Similarly, the measuring and monitoringequipment 291 can produce and/or convey signals providing feedback onthe operation of the system 200 to the control system 297 via thecommunications system 292. For example, in some embodiments, themeasuring and monitoring equipment 291 can receive a control signal (orinstruction) via the communication system 292 related to the operationof the gas extraction pump 231 and can terminate the operation of thegas extraction pump 231 in response to that control signal. In someembodiments, the measuring and monitoring equipment 291 can receive acontrol signal (or instruction) via the communication system related toclosing a valve in system 200. For example, the measuring and monitoringequipment 291 can close a valve to cease the venting of the extractedgas to the atmosphere or to begin delivery of the extracted gas to thegas incinerator 253.

The data storage and reporting system 295 can receive, store, makeavailable, and/or report data or information generated by the measuringand monitoring equipment 291. For example, the data storage andreporting system 295 can include a database to store information relatedto performance (e.g., efficiency, a report associated with regulatorycompliance, the amount of environmental attribute credits (e.g., carbonoffset credits) generated) of the system 200. The data storage andreporting system 295 can report such information via, for example,electronic mail, short message service (“SMS”) messages, Really SimpleSyndication (“RSS”) or some other syndication feed, and/or otherreporting channels. In some embodiments, the data storage and reportingsystem can place an automated telephone call using and interactive voiceresponse (“IVR”) to provide reports related to system 200.

The data storage and reporting system 295 can make data or informationavailable via a web server and/or an application programming interface(“API”). For example, data and information related to system 200 andstored at the data storage and reporting system 295 can be accessiblevia a website providing charts and/or other presentation of that data.Additionally, the data storage and reporting system can provide an APIthat can provide access to the data and information stored at the datastorage and reporting system.

In some embodiments, the measuring and monitoring equipment 291, and anysimilar system or components described herein (e.g., the controlassembly 590), can provide batch or periodic updates to the data storageand reporting system 295 via the communications system 292. For example,the measuring and monitoring equipment 291 can provide daily data orinformation dumps to the data storage and reporting system 295. In someembodiments, the measuring and monitoring equipment 291 can provide nearor substantially real-time updates to the data storage and reportingsystem 295. For example, the measuring and monitoring equipment 291 canprovide data or information dumps to the data storage and reportingsystem 295 at substantially the same time as the data or information isgenerated at the measuring and monitoring equipment 291. In someembodiments, some data and/or information is provided to the datastorage and reporting system 295 in batch updates and other data and/orinformation is provided to the data storage and reporting system 295 innear real-time. For example, data related to a reduction in greenhousegas emissions, compliance with regulations associated with gas emissionsand/or the number of environmental attribute credits (e.g., carbonoffset credits) generated by system 200 can be provided in daily batchupdates, and alarm information (e.g., the flame in the gas incineratorhas failed) can be provided in near real-time.

In some embodiments, data and/or information can be encrypted orotherwise securely stored at the data storage and reporting system 295.For example, data received at the data storage and reporting system 295can be encrypted at the data storage and reporting system. In someembodiments, the communication system or the measuring and monitoringequipment 291 can encrypt data before those data are sent to the datastorage and reporting system. In some embodiments, the communicationsystem can use secure or encrypted channels such as Secure Sockets Layer(“SSL”) or Secure Shell (“SSH”) tunnels to send and receive data.

The data storage and reporting system 295, and any of the componentsand/or systems described herein having similar functionality, caninclude various commercially available components including datareporting and warehousing solutions marketed to the mining industry.

The control system 297 is configured to control the performance andoperation of various components of system 200. For example, the controlsystem 297 can control the performance of the gas extraction pump 231,the gas incinerator 253, and/or the measuring and monitoring equipment291. As discussed above, the control system can communicate with themeasuring and monitoring equipment 291 to control various components ofsystem 200. In some embodiments, system 200 can include a control module(not shown) separate from the measuring and monitoring equipment 291configured to receive control signals via the communication system 292from the control system 297 to implement control of system 200. In otherwords, the control system can be operatively coupled to components ofsystem 200 via the communication system 292, the measuring andmonitoring equipment 291, and/or a control module.

More specifically, for example, the control system 297 can control thefollowing parameters of system 200: the start-up and stoppage of the gasextraction pump 231, the speed of gas extraction pump (e.g., increasingor decreasing the speed in response to certain conditions), the amountof extracted gas supplied to the power source 232 (e.g., the air to fuelratio of the gas supplied to the engine), the start-up and stoppage ofthe gas incinerator 253, the burn profile of the gas incinerator 253,and/or other operational parameters of other components of system 200.Thus, the control system 297 can coordinate and/or integrate operationof the components of system 200. Furthermore, the control system 297 canprovide calibration and adjustment of the measuring and monitoringsystem 291 and/or other components of system 200. The control system 297can include various commercially available control systems.

FIG. 5 is a schematic diagram of a gas extraction, incineration andmonitoring system 300, according to an embodiment. System 300 includes agas well delivery pipe 1, a starter fuel supply 2, an engine (or powersource) 3, a primary fuel line 4, a gas suction pipe 5, a fluid machine(or pump) 6, a mechanical coupling 7, a vent 8, a flow interface control9, and incinerator delivery line 10, a control and monitoring system 11,an incinerator 12, and a gas control 13. Each of these components isdiscussed in detail below.

The gas well delivery pipe 1 can be any suitable pipe or borehole thatcan be placed in fluid communication with a source of gas (e.g., the gobor other extraction well associated with a mining operation, a landfillvent, a gas well associated with gas exploration or the like). In use,the fluid machine 6 removes or extracts gas from the gas well via thegas well delivery pipe 1. As illustrated in FIG. 5, in some embodiments,the gas well delivery pipe 1 can include a valve configured tofluidically isolate the gas well and the fluid machine 6. Although thegas well delivery pipe 1 is shown as being fluidically coupled to thefluid machine 6 via the gas suction pipe 5, in other embodiments, thegas well delivery pipe 1 can be directly coupled or connected to thefluid machine 6. In yet other embodiments, as described in more detailherein, the fluid machine 6 can be coupled to the gas well delivery pipe1 via a gas well adapter (see e.g., the gas well adapter 510) that caninclude safety valves, a flame arrestor, a water (or condensation) trapelement and/or an electrical isolation member. The inclusion of suchcomponents within a gas well adapter can depend on the specificcharacteristics of and/or regulations associated with the environment inwhich the system 300 is being used.

The fluid machine 6 extracts gas from the gas well via the gas welldelivery pipe 1 and the gas suction pipe 5. As shown in FIG. 5, thefluid machine 6 outputs the extracted gas at an outlet of the fluidmachine 6. Thus, the fluid machine 6 produces a flow of gas from the gaswell and/or produces a pressurized gas at its outlet.

The fluid machine 6, and any of the fluid machines described herein (seee.g., fluid machine 531), can be any suitable rotary pump, compressorand/or blower designed to produce a vacuum on the gas suction pipe 5 atthe inlet of fluid machine 6, and to deliver gas at an outlet of fluidmachine 6. The fluid machine 6 can be one of many types or designs basedon the desired gas flow, characteristics of the gas, and may be of anysuitable pump design, such as liquid ring pump, centrifugal fan, screwcompressor, reciprocating compressor, a roots type positive displacementlobed pump, and/or any other pump or compressor. In some embodiments,the fluid machine 6 can include a blower to produce a vacuum at the headof the fluid machine 6. In some embodiments, the fluid machine 6 can beconfigured to produce a flow rate of between 300 and 3000 CFM of gasextracted from the gas well. In some embodiments, the fluid machine 6can be one of various commercially available gas extraction pumps usedto extract gas from underground mining cavities and/or landfills.

The fluid machine is driven by the power source 3. More particularly,the power source 3 is operatively coupled to the fluid machine 6 via amechanical coupling 7. As illustrated in FIG. 5, the power source 3 andthe fluid machine 6 can be collocated or integrated within a singleassembly. In some embodiments, the fluid machine 6 and the power source3 can be an integrated unit, such as, for example, the any of thesystems produced by KSD Enterprises, which are described in U.S. Pat.No. 6,578,559, entitled “Methane Gas Control System,” and U.S. PatentPublication No. 2008/0011248, entitled “System and Method for Control ofa Gas,” each of which is incorporated herein by reference in itsentirety. In some embodiments, the assembly including the power source 3and the fluid machine 6 can be mounted on a wheeled chassis and/or othermobile structure (e.g., a pallet or skid configured to be manipulatedvia a fork lift or mobile crane). In yet other embodiments, the controland monitoring system 11 and/or the incinerator 12 can also beintegrated within a single assembly that includes the power source 3 andthe fluid machine 6. Embodiments showing such arrangements are describedbelow (see e.g., system 500 and system 600, described below).

As described above with respect to the system 200, the power source 3can be a spark ignition reciprocating gas fuelled engine that isconfigured to produce power from variable concentration and/or lowquality gaseous fuels such extracted methane and other hydrocarbons andair. In some embodiments, the power source 3 can produce power usingmultiple sources and/or types of fuel. For example, in some embodiments,the power source 3 can operate using propane, methane and/or a mixtureof the two. Thus, as shown in FIG. 5, the power source 3 can operateusing the starter fuel supply 2 (which can include a first source offuel) during certain periods of system operation and the extractedmethane during other periods of system operation.

The starter fuel supply 2 can be, for example, a propane tank, anysuitable liquefied petroleum gas (“LPG”) tank or other such piped orbottled fuel configured to provide an alternative fuel source for thepower source 3. In this manner, the starter fuel supply 2 can provideoperational fuel to power source 3 during system “start up” (e.g.,during the initial extraction of gas from the gas well). Said anotherway, the starter fuel supply 2 can provide fuel to the power source 3 toallow the power source 3 to drive the fluid machine 6 to draw gas fromthe gas well prior to the time period during which the extracted gasflow is sufficient to operate the power source 3. After system 300begins to draw a sufficient quantity or flow of gas from the gas well, aportion of the extracted gas can be conveyed to the power source 3 (viathe primary fuel line 4) to provide fuel for the power source 3.Similarly stated, after gas delivered to the power source 3 via primaryfuel line 4 has reached a sufficient quality and/or flow to sustainoperation of power source 3, the gas via primary fuel line 4 can beconveyed to the power source 3 and starter fuel supply 2 can be switchedoff.

In some embodiments, the starter fuel supply 2 can be methane or othergas extracted from the gas well. Thus, after the extracted gas deliveredvia the primary fuel line 4 is of sufficient quality and/or flow tooperate the power source 3, some of the gas extracted from the gas wellcan be provided to starter fuel supply 2 to recharge or refill areceiver containing the starter fuel 2. Thus, starter fuel supply 2 canbe replenished by the gas extracted from the gas well by system 300. Inthis manner, the power source 3 and/or the system 300 can be repeatedlyshut down and restarted without the need to provide fuel for the starterfuel supply 2 from an external source (e.g., a gas pipeline, an externalrefueling operation or the like).

The extracted gas can be delivered from the outlet of the fluid machine6 to the vent 8, to the incinerator 12 and/or to the power source 3. Inparticular, the primary fuel line 4 is operatively coupled to the powersource 3 and the output of fluid machine 6. Thus, at least a portion ofthe extracted gas (e.g., the flammable methane) can be conveyed from theoutlet of fluid machine 6 to power source 3 via the primary fuel line 4.As described above, the power source 3 can use the extracted gasdelivered via primary fuel line 4 as operational fuel. In someembodiments, the amount (e.g., the total mass or volumetric flow rate)of extracted gas provided to power source 3 via primary fuel line 4and/or the byproducts of the combustion products produced by the powersource 3 can be measured by, for example, control and monitoring system11. In this manner, an indication of the reduction in greenhouse gasemissions, including a indication of the compliance with applicableregulations (and/or any environmental attribute credits (e.g., carbonoffset credits) resulting therefrom) can be generated based, at least inpart on, the amount of methane (or other hydrocarbon) gas combustedwithin power source 3.

Additionally, at least a portion of the extracted gas can be deliveredto the incinerator 12 and/or the vent 8 via the flow interface control9. More particularly, the flow interface control 9 can include a valveto selectively control the amount of extracted gas that is delivered tothe incinerator 12 and the vent 8. Thus, when the valve of the flowinterface control 9 is closed, none of the extracted gas is delivered tothe vent 8, and the remainder of the extracted gas (i.e., the portionnot conveyed to the power source 3) is delivered to the incineratordelivery line 10. When the valve of the flow interface control 9 isfully opened, none of the extracted gas is delivered to the incineratordelivery 12, and the remainder of the extracted gas (i.e., the portionnot conveyed to the power source 3) is delivered to the vent 8. When thevalve of the flow interface control 9 is partially opened, a firstportion of the remainder of extracted gas is delivered to theincinerator delivery 12, and a second portion of the remainder of theextracted gas is delivered to the vent 8.

The flow interface control 9 can be controlled via the control andmonitoring system 11, and can control, direct and/or divert gas to thevent 8, the primary fuel line 4 and/or the incinerator delivery line 10,as described above. The flow interface control 9 can include, forexample, any suitable mechanical, diaphragm, pneumatic,electro-hydraulic, electrical control, and/or relief valves. In someembodiments, the flow interface control 9 can include one or more flamearresters, secondary compressors, flow devices or the like. Althoughshown as including a single control valve, in other embodiments, theflow interface control 9 can include any number of valves and/orfeedback mechanisms.

Thus, the flow interface control 9 and the control and monitoring system11 can collectively function to ensure that the appropriate amount ofextracted gas is supplied to the power source 3, the incinerator 12 andthe vent 8. For example, during periods of system start-up, duringincinerator 12 shutdown, and/or at certain other times, a portion of thegas extracted from a gas well can be released directly to the atmospherethrough vent 8. Said another way, the flow interface control 9 and/orthe gas control valve 13 can be actuated or adjusted to ensure than gasdoes not vent through incinerator 12, but rather vents through the vent8, which is separate from the incinerator 12. The extracted gas can thusbe vented to atmosphere via vent 8 when conditions are not suitable forcombustion within the incinerator 12. For example, during start-upphases, the fluid machine 6 may produce an insufficient volume and/orgas pressure for operation of incinerator 12. Additionally, duringstart-up phases, the concentration of combustible methane (or otherhydrocarbons) within the extracted gas may be below a predeterminedthreshold for the desired operation of the incinerator 12. By releasingthe extracted gas directly to the atmosphere via the vent 8 rather thanvia the incinerator 12, the control and monitoring system 11 can accountfor the portion extracted gas that is not oxidized to ensure accuracy ofany determination of the reduction in greenhouse gas emissions producedby the system 300. In some embodiments, this arrangement allows thesystem 300 to account for such venting and ensure that the accuracy ofthe information associated with greenhouse gas emissions (and anyregulatory compliance related thereto) and/or environmental attributecredits (e.g., carbon offset credits) generated is within the guidelinesset forth by the regulatory agencies associated with the regulationsand/or the certifying agencies associated with the environmentalattribute credits (e.g., carbon offset credits). In addition to ensuringthe integrity of the calculations associated with the reduction ingreenhouse gas emissions, venting a portion of the extracted gas via aseparate flow path can abate certain safety issues. The safety hazardsassociated with venting through the incinerator 12 can be particularlyacute in a remote application without an operator present at the site ofsystem 300. Furthermore, in some regions venting through incinerator 12can be prohibited.

The incinerator 12 receives the extracted gas flow via the incineratordelivery line 10. In some embodiments, incinerator delivery line 10 caninclude a secondary compressor to boost the gas pressure for delivery tothe incinerator 12. For example, if fluid machine 6 does not produce agas flow at a sufficient pressure for safe operation of incinerator 12,or if pressure losses resulting from flow through the incineratordelivery line 10 and/or other plumbing excessively reduce the gaspressure within incinerator delivery line 10, the incinerator deliveryline 10 can include a secondary compressor. In some embodiments, asecondary compressor can be included in incinerator delivery line 10 andcan be controlled by control and monitoring system 11. For example, asecondary compressor can be activated if gas pressure within incineratordelivery line 10 falls below a threshold and deactivated after a periodof time and/or after the gas pressure exceeds a threshold. Incineratordelivery line 10 can also include isolation components and/orinstrumentation to interface between the flow interface control 9 andincinerator 12.

Similarly, a gas control 13 can be disposed within and/or operativelycoupled to the incinerator delivery line 10. The gas control 13 can becontrolled via control and monitoring system 11, and can control anddirect or divert gas to incinerator 12. Gas control valve 13 caninclude, for example, mechanical, diaphragm, pneumatic,electro-hydraulic, electrical control, and/or relief valves. In someembodiments, gas control 13 can include flame arresters.

The incinerator 12 is a device configured to thermally oxidize flammablegasses extracted from the gas well. The incinerator 12 can include anytype of enclosed burner or flare configured to combust the incoming gas.The incinerator 12 can include gas pressure control, flame failuredetectors, flame arrester, and/or additional instrumentation devices orcontrols.

In some embodiments, the incinerator 12 can be a unitary assembly. Inother words, the incinerator 12 can include multiple components coupledtogether to operate as described herein. In some embodiments, asdescribed herein, the incinerator 12 can be mounted or attached to amobile chassis and/or transportation platform (see e.g., system 600described below). These and/or other configurations can be used toincrease mobility of incinerator 12 in a particular application ormining environment. The incinerator 12 can be (or include) one or morecommercially available products.

The control and monitoring system 11 can be substantially similar to themeasuring and monitoring system 291, the control system 297 discussedabove in relation to FIG. 2, and/or any of the control systems describedherein. Control and monitoring system 11 operates to monitor theoperation of the power source 3, the fluid machine 6, the flow interfacecontrol 9, the gas control 13, the incinerator 12, and/or othercomponents of system 300. For example, control and monitoring system 11can shut down the system 300 (e.g., remove ignition from the powersource 3, close any number of valves within the system or the like) upona fault condition, can provide inputs to ensure the desired operation ofthe flow interface control 9 and the incinerator 12, and/or can measureoperation time, gas temperature, gas pressure, volumetric flow, methaneconcentration and/or other flow characteristics to generate anindication of the reduction of greenhouse gas emissions (e.g., to ensureregulatory compliance) and/or to generate environmental attributecredits (e.g., carbon offset credits), as described herein.

In some embodiments, system 300 can include more or fewer componentsthan illustrated in FIG. 3. For example, gas control 13 can be removedand the flow interface control 9 can be the sole control of the gas flowto incinerator 12. In some embodiments, system 300 can includeadditional gas controls. Furthermore, system 300 can include additionalsensors, transducers, and/or measurement devices of the types describedherein.

In some embodiments, multiple systems 300 can be configured to operatein tandem and/or can share components. For example, multiple systems 300can share a single incinerator 12 and/or vent 8. Thus, multipleincinerator delivery lines 10 can interface with a single incinerator12. Additionally, multiple fluid machines 6 can be operatively coupledto a single gas well delivery pipe 1 and/or a single gas suction pipe 5.Moreover, flow interface controls 9 can be operatively coupled to asingle vent 8. Furthermore, multiple fluid machines 6 can be coupled toa single power source 3 or, alternatively, multiple power sources 3 canbe coupled to a single fluid machine 6.

FIG. 6 is a schematic diagram of a gas extraction, incineration andmonitoring system 400, according to an embodiment. System 400 issubstantially similar to system 300 discussed above; however, system 400is substantially enclosed within housing 14. Housing 14 can be, forexample, a shipping container, a mobile trailer mounted on a wheeledchassis, and/or some other housing or container. Additionally, similarto system 300, system 400 includes a gas well delivery pipe 1, a starterfuel supply 2, a power source (or motor) 3, a primary fuel line 4, a gassuction pipe 5, a fluid machine (or pump) 6, a mechanical coupling 7, avent 8, a flow interface control 9, an incinerator delivery line 10, anincinerator 12, and a gas control 13. System 400 can also include acontrol and monitoring system (not shown).

System 400 is an integrated, self-contained gas extraction, incinerationand monitoring system. Thus, system 400 can have an external coupling orpipe that can be coupled to the gas well delivery pipe 1 and otherwiseoperated within housing 14. As illustrated in FIG. 6, the vent 8 and theincinerator 12 can be open to the outside of housing 14 such thatmethane and the byproducts of the incinerated methane can be expelledinto the atmosphere rather than into housing 14.

FIG. 7 is a schematic illustration of a gas extraction, incineration andmonitoring system 500. The system 500 includes a transportation platform502, a gas well adapter 510, an extraction assembly 530, an interfaceassembly 540, an incinerator assembly 550, a vent assembly 570, and acontrol assembly 590. The system is 500 is configured to extract a wasteor vented gas (e.g., methane gas); utilize the extracted gas to producemechanical, electrical, and/or heat energy; incinerate extracted gas;vent a portion of the extracted gas to the atmosphere under certainconditions; and/or monitor and/or otherwise track the reduction ofpollutant constituents. Each of the components of the system 500 aredescribed below.

The system 500 is similar to and can have similar components to thesystem 300 and the system 400. Accordingly, components within the system500 that are similar components described above with respect to systems300 and 400 can have similar structure and/or perform similar functionsas described above. By way of example, the fluid machine 531 of thesystem 500 can be similar in configuration to the fluid machine 3 of thesystem 300. Furthermore, any component described in relation to system300 and/or system 400, can be included in the system 500, andvice-versa.

The transportation platform 502 is a mobile platform configured tofacilitate the ingress and egress of the system 500 into and from afluid extraction location (e.g., an area adjacent a gas well GW). Thetransportation platform 502 includes wheels 503 and an earth ground 507,and can be configured to accept modular mounted assemblies, such asthose described herein. The transportation platform 502 includes acoupling 519 that can be used to removably couple the gas well adapter510 and/or any other portion of the system 500 (e.g., the vent assembly(570) to the transportation platform 502 during transportation of thesystem 500. The coupling 519 can be located in any suitable locationalong transportation platform 502. For example, as shown in FIG. 7, thecoupling 519 can be located at an end of the transportation platform502, to coincide with the position of the gas well adapter 510. In thismanner, the gas well adapter 510 can be removably coupled to thetransportation platform 502 to facilitate removal of the gas welladapter 510 after transportation of the system 500 to the extractionlocation.

In some embodiments, the transportation platform is a flatbed trailer.In some embodiments, the transportation platform 502 is dimensionedsimilar to a standard trailer to facilitate portability of thetransportation platform and the system 500, such as, for example, alongroads, rails, and on ships. Similarly stated, in some embodiments, thetransportation platform 502 and the components coupled thereto can beconfigured to comply with a standard (e.g., a state standard for sizeand/or weight) for on-road transportation. Although shown as includingwheels 503, in other embodiments, a transportation platform can includetracks, skids, etc., in lieu of or in addition to wheels 503.

The earth ground 507 is configured to be disposed between thetransportation platform 502 and the ground to reduce the likelihood ofthe transmission of electricity (e.g., via a lightning strike and/orother static electric charge) from the system 500 to the gas well GW.The earth ground 507, therefore, is a substantially non-conductivemember that can be placed, for example, between the mounting supportsand/or any outriggers (not shown in FIG. 7) of the transportationplatform 502 and the ground.

The gas well adapter 510 is configured to connect the remainder of thesystem 500 (e.g., the extraction assembly 530) to the source of gas(e.g., the gas well GW). Although shown as being coupled to a mine gaswell GW, the gas well adapter 510 is configured to be coupled to a widevariety of gas sources, including mine sources, landfills, wellsassociated with geological exploration or the like. Moreover, asdescribed below, the gas well adapter 510 includes a variety ofdifferent components and/or features to enhance the safety of themethane extraction operation. Such functionality includes, for example,electrically isolating the gas well GW from the remainder of the system500, the inclusion of one or more flame arrestors (e.g., flame arrestor515) to limit the propagation of a flame within the plumbing and/or oneor more electronically controlled valves (e.g., the first valve 516and/or the second valve 517) to automatically shut off the gas flowunder certain conditions. Although the gas well adapter 510 is describedbelow as including certain components and functionality, in otherembodiments a gas well adapter can include only a portion of thecomponents and functionality as described with respect to the gas welladapter 510.

The gas well adapter 510 includes a frame 511, an inlet member 512, anoutlet member 513, a first valve 516, a second valve 517, at least onepressure sensor 504, a temperature sensor 506, a flame arrestor 515, andan electrical isolation member 514. The frame 511 can be any suitableframe. In some embodiments, the frame can be a skid that is configuredto be moved by a forklift or other industrial equipment. In someembodiments, the frame can be a four foot by six foot frame tofacilitate portability of the gas well adapter 510. Although shown asbeing removably attached to the transportation platform 502 via thecoupling 519, in other embodiments, the frame 511 can include a coupling(not shown in FIG. 7) to facilitate mounting to the transportationplatform 502. In other embodiments the frame 511 can be substantiallypermanently attached to the transportation platform 502. In yet otherembodiments the frame can be separate from the transportation platform502.

The inlet member 512 is configured to be coupled to any number ofdifferent outlet pipe configurations that may be employed with the gaswell GW. For example, the inlet member 512 can be coupled to any rangeof pipe sizes (e.g., 6 inch pipe, 8 inch pipe) and any length of pipeextending above the surface (e.g., ranging from a pipe that issubstantially flush with the surface to a pipe that extends four feet ormore from the surface). Moreover, the inlet member can be configured tobe coupled to any flange connection. For example, in some embodiments,the inlet member 512 can include a traditional pipe flange. In otherembodiments, the inlet member 512 can include a quick-connect flange(e.g., a flange that includes captive bolts or the like and/or thatotherwise facilitates quick connection to the gas well GW flange.

In some embodiments, the inlet member 512 can have a flexible portion toallow the flange or connection portion of the inlet member 512 to bepositioned in any suitable orientation to be coupled to the gas well GW.For example, in some embodiments, the inlet member 512 includes aflexible portion configured to couple the inlet member 512 to the outletpipe of the gas well GW forming an angle A (as shown in FIG. 7) with aground surface of between zero and one hundred-eighty degrees. In otherembodiments the inlet member 512 includes a flexible portion configuredto couple the inlet member 512 to the outlet pipe forming an angle witha ground surface of between zero and ninety degrees. In this manner, gaswell adapter 510 can be positioned in any orientation relative to thesurface, which can also be in any suitable orientation. For example thegas well adapter 510 can be positioned above the gas well GW (e.g., thegas well GW can be at the surface SU; down a hill or mountain side; orwithin a crater/quarry, etc.), substantially level with the gas well GW,or below the gas well GW.

The outlet member 513 is configured to be coupled to the extractionassembly 530. As described below, the outlet member 513 can beselectively placed in fluid communication with the inlet member 512and/or the gas well GW. A gas flow from the gas well GW can therefore beconveyed from the gas well GW to the extraction assembly 530 via theoutlet member 513. Although the outlet member 513 is shown in FIG. 7 asbeing coupled to the extraction assembly 530, in other embodiments, theoutlet member 513 can be coupled to any suitable receiver, such as, forexample, a gas reservoir or tank, an incinerator, a vent stack or thelike.

The first valve 516 and the second valve 517 operate to selectivelyfluidically isolate the gas well GW from the system 500. The first valve516 and the second valve 517 can be any suitable valve, such as, forexample, a gate valve, a ball valve, a check valve or the like. In someembodiments, the first valve 516 can be a gate valve (e.g., andisolation valve), and the second valve 517 can be a check valve (e.g., anon-return valve). For example, in some embodiments, the first valve 516and/or the second valve 517 can be a 1550 series gate valve manufacturedby Milwaukee Valve Company, a 10 series ball valve manufactured byMilwaukee Valve Company, or a 1570 series check valve manufactured byMilwaukee Valve Company. Although shown as including two valves, inother embodiments, the gas well adapter 510 can include more or fewervalves, and can include any combination of isolation valves and/ornon-return valves.

As described below, the first valve 516 and the second valve 517 areelectronically controlled. In particular, the operation of first valve516 and second valve 517 is described in more detail with reference toFIGS. 14 and 15. In other embodiments, however, the first valve 516 andthe second valve 517 can be controlled and/or operated in any suitablemanner (e.g., electronically, manually, pneumatically, hydraulically,and/or the like).

The flame arrestor 515 is disposed between the inlet member 512 and theoutlet member 513 and operates to allow flow of gas therethrough whileimpeding the propagation of flame and/or explosions within the gas welladapter 510. The flame arrestor 515, which can also be referred to as aflame detonator, can be any suitable flame arrestor that will allow thedesired range of gas flow therethrough (e.g., between 30 and 3000 CFM)while impeding the propagation of flames. In general, a flame arrestorcan be classified based on whether it is disposed in-line or at the endof the line; whether it is configured to impede deflagration,detonation, or both; stable and/or unstable detonation; and short timeor endurance burning. In some embodiments, the flame arrestor 515 can bean in-line flame arrestor and can be configured to impede deflagration,stable detonation, and short time burning. For example, in someembodiments, the flame arrestor 515 can be a RMG 933-SE manufactured byHoneywell Process Solutions. In some embodiments, the flame arrestor 515can be configured for use with stable and/or unstable detonation,deflagration, and for short-time and/or endurance burning.

The gas well adapter 510 includes a pressure sensor 504 disposed at aninlet of the flame arrestor 515, and configured to measure the pressureof the gas flow entering the flame arrestor 515, and a pressure sensor504 disposed at an outlet of the flame arrestor 515, and configured tomeasure the pressure of gas exiting the flame arrestor 515. The pressuresensors 504 can be configured to measure the gas pressure within apredetermined range, as described below. Moreover, the pressure sensors504 can be operatively coupled to the control assembly 590. In thismanner, the control assembly 590 can monitor the pressure drop acrossthe flame arrestor 515 to determine whether the flame arrestor 515 needsto be cleaned, have maintenance performed, and/or be replaced. Thesignals from the pressure sensors 504 can also be used by the controlassembly 590 to determine whether a flame event has occurred adjacentthe flame arrestor 515. Although shown as including two pressuresensors, in other embodiments, the gas well adapter 510 can include anynumber of pressure sensors. For example, in some embodiments, the gaswell adapter 510 can include a pressure sensor upstream of the firstvalve 516. Such an arrangement can be used, for example to determinewhether the pressure within gas well GW is within the desired range foroperation of the system 500.

The gas well adapter 510 includes a temperature sensor 506 disposedadjacent the flame arrestor 515 that is configured to measure thetemperature within the flame arrestor 515. The temperature sensor 506can be operatively coupled to the control assembly 590. In this manner,when the temperature of the flame arrestor rises above a predeterminedthreshold, control assembly 590 can produce a control signal indicatingthat a flame, explosion or other unsafe condition is present. In someembodiments, the control signal can be used to produce an indication toan operator to shut down the system 500. In other embodiments, thecontrol signal can transmitted to the first valve 516, the second valve517 and/or any other component within the system 500 to automaticallyshut down the system 500. In some embodiments, the gas well adapter 510can include more or fewer (i.e., no) temperature sensors 506. Forexample, the gas well adapter 510 can include a temperature sensorbefore and/or after the flame arrestor 515.

The electrical isolation member 514 is disposed between the outletmember 513 and the inlet member 512 and prevents and electrical charge(e.g., from a lightning strike or other static charge) from travelingthrough the system 500 and into the gas well GW. The electricalisolation member 514 includes non-conducting material, and in someembodiments, the electrical isolation member can be a section of pipe.Although the electrical isolation member 514 is described as beingdistinct from the outlet member 513, in some embodiments the outletmember can include an isolation portion that functions to electricallyisolate the inlet member 512 from the outlet member 513.

As described in more detail below, components of the gas well adapter510 can be operably coupled to the control assembly 590. In this manner,the control assembly 590 can allow automated control of valves, canproduce outputs related to status of flow, status of flame arrestor orthe like.

The extraction assembly 530 of the system 500 includes a fluid machine531, a power source 532, and is configured to extract gas (e.g., methanegas) from the gas well GW. Said another way, the extraction assembly 530is configured to be fluidically coupled to the gas well GW and produce aflow of fluid therefrom. Although the extraction assembly 530 isdescribed below as including certain components and functionality, inother embodiments an extraction assembly can include only a portion ofthe components and functionality as described with respect to theextraction assembly 500. In addition to extracting fluid from a source,extraction assembly 530 is configured to provide power to the system 500and/or reduce certain pollutant constituents (e.g., by combusting theextracted gas, which can include methane). Although the extractionassembly 530 is shown as being coupled to the transportation platform502, in other embodiments, the extraction assembly 530 can be disposedapart from the transportation platform 502. For example in someembodiments the extraction assembly 530 can be removably and/ormodularly coupled to the transportation platform 502.

The fluid machine 531 is configured to produce a flow of extracted gasto the system 500, to produce a fluid flow to a power source 532, and tobe driven by the power source 532. The fluid machine 531 is coupled tothe outlet member 513 of gas well adapter 510. The fluid machine 531includes an outlet member 537 to fluidically couple the fluid machine531 to the interface assembly 540. The fluid machine 531 can be anysuitable blower or other gas pump. For example, in some embodiments, thefluid machine can be a multi-stage centrifugal blower.

The fluid machine 531 can be configured to produce any suitable flowrate of and/or pressure within the gas extracted from the gas well GW.In some embodiments, the fluid machine 531 can produce a fluid flow rateof between about 250 cubic feet per minute (“CFM”) and about 2500 CFM.In this manner, the turndown ratio of the system 500 can beapproximately 10:1 (2500/250). In other embodiments, the fluid machine531 can have a greater range (e.g., 50 CFM to 5000 CFM), a lesser range(e.g., 500 CFM to 2000 CFM), and/or a different range (e.g., 750 CFM to3000 CFM). In some embodiments the fluid machine 531 can produce flowrates greater than 3000 CFM and/or less than 50 CFM. As described inmore detail below, the fluid machine 531 can be dynamically balancedwith the other fluid flow components (e.g., the flame arrestor 515, theincinerator assembly 550 and the valves 516, 517) such that the system500 can produce an overall turndown ratio of approximately 10:1.

Similar to the system 300 described above, the outlet member 537 of thefluid machine 531 is fluidically coupled to the power source 532. Thus,at least a portion of the gas flow produced by the fluid machine 531 isconveyed to the power source 532. Said another way, the fluid machine531 can direct a portion of the extracted gas flow (e.g., a combustiongas useable as fuel) to the power source 532, and the power source 532can use the portion of extracted gas flow as fuel, as described below.

The power source 532 can be any suitable source of power configured todrive the fluid machine 531 and/or provide power to the other componentsof the system 500 as described herein. In this manner, the system 500can operate independent of any external power supply and/or power grid.Said another way, the power source 532 can provide all of the powerneeds of the system 500. In some embodiments, the power source 532 isconfigured to convert a portion of the fluid extracted from the gas wellGW by the fluid machine 531 into power. For example, in someembodiments, the power source 532 is an engine configured to convert aportion of the extracted gas into power, similar to the power source 3described above with reference to the system 300. In other embodiments,power source 532 can be any other suitable power source, such as, forexample, a turbine, a fuel cell, or a combination of power sources.

The power source 532 can supply power to the fluid machine 531 via anysuitable power transmission mechanism. In some embodiments, the fluidmachine 531 can be mechanically coupled to the power source 532. In suchembodiments, the fluid machine 531 can be coupled to the power sourcevia a transmission (not shown) and/or other gearing system (e.g., amanual transmission, automatic transmission, a transmission with asingle gear, multiple gears, and/or a constantly variable transmission).In this manner, the coupling between the power source 532 and the fluidmachine 531 can be changed to increase or decrease the fluid flowproduced by the fluid machine 531. In other embodiments, the fluidmachine 531 is mechanically coupled to an electric motor (not shown),and the electric motor can be electrically coupled to the power source532. The electric motor can be any electric motor (e.g. single speed,variable speed, etc) suitable to drive the fluid machine 531.

As described in more detail below, components of the extraction assembly530 can be operably coupled to the control assembly 590. Moreparticularly, the fluid machine 531 and the power source 532 can beoperably coupled to system controller 597 to allow automated control ofpower source 532 and/or the fluid machine 531. Additionally, electroniccontrol assembly 590 can produce outputs related to status of flow, thestatus of components or the like.

The interface assembly 540 is configured to direct at least a portion ofthe fluid extracted from the gas well GW to one or more destinationsbased on a variety of factors, such as, for example, the flow rate ofthe fluid being extracted, the chemical composition of the fluid beextracted, the power demand of the system 500, the operation status ofcertain components of the system 500, and/or for safety and/ormaintenance purposes. Specifically, the interface assembly 540 isconfigured to direct at least of portion of the fluid extracted from thegas well GW to the incinerator assembly 550 and/or the vent assembly570. In this manner when conditions for combustion of the extracted gaswithin the incinerator 570 are not suitable (e.g., any one of theconcentration, the flow rate, transient fluctuations in gas flow or thelike is not suitable for combustion), the interface assembly 540 candirect at least a portion of the extracted gas to the vent assembly 570.

The flow interface assembly 540 includes an inlet member 541, a firstoutlet member 542, and a second outlet member 543. The flow interfaceassembly 540 also includes one or more valves (not shown in FIG. 7) toselectively control the amount of extracted gas that is delivered to theincinerator assembly 550 and/or the vent assembly 570.

The inlet member 541 is configured to direct fluid from the extractionassembly 530 to the interface assembly 540. The inlet member 541includes a series of sensors disposed therein, including at least onepressure sensor 504, a temperature sensor 506, and a fluid concentrationsensor 508. The fluid concentration sensor 508 can measure and/orotherwise monitor the concentration of one or more constituents,chemicals, or compositions within the gas flow. In some embodiments, thefluid concentration sensor 508 can measure and/or monitor theconcentration of certain constituents (e.g., methane) in the gas beingextracted from the gas well GW. As described herein, the signals each ofthese sensors, including the fluid concentration sensor 508, can be usedby the control assembly 590 to adjust the operation of the system 500.For example, the control assembly 590 can shut down the system 500(e.g., remove ignition from the power source 532, close any number ofvalves within the system or the like) based, at least in part, on thesignals each of these sensors. More particularly, the control assembly590 can shut down the system if the concentration of methane within thegas flow drops below a particular level (e.g., 25 percent).

Signals from the pressure sensors 504 can also be used to calculate theflow rate of fluid between the extraction assembly 530 and the interfaceassembly 540. In some embodiments, the inlet member 541 can include anorifice, one pressure sensor 504 disposed upstream of the orifice andone pressure sensor 504 disposed downstream of the orifice. The orificecan be sized such that the pressure drop across the orifice can be usedto determine flow rate through the orifice. In some embodiments, flowrate and concentration info can be corrected for changing atmosphericconditions (e.g., pressure and temperature). In some embodiments, flowdata (e.g., concentration, flow rate, etc.) and atmospheric data can bemonitored and stored by the systems within the control assembly 590 andcan be combined with other system information to generate an outputassociated with the amount of methane, and/or other pollutantconstituent, that is combusted by the incinerator assembly 550. Thisinformation can by used by the control assembly 590 to produce anindication of the reduction of greenhouse gas emissions associated withthe extraction process, as described herein. In some embodiments, thecontrol assembly 590 can produce a real-time calculation of thereduction in greenhouse gas emissions.

The interface assembly 540 includes any suitable mechanism, valve(s),and/or valve arrangement for directing flow to the first outlet 542 andthe second outlet 543. The first outlet 542 directs fluid to theincinerator assembly 550, and the second outlet 543 directs fluid to thevent assembly 570. The control assembly 590 can monitor the interfaceassembly to determine the amount of a gas constituent, such as methane,that is being directed to the incinerator assembly 550 and to the ventassembly 570, and can therefore calculate the amount of methanecombusted as a function of time, as well as the amount of methane ventedto the atmosphere.

The interface assembly 540 can be operatively coupled to the controlassembly 590. More particularly, the interface assembly 540 can beoperably coupled to the system controller 597 to allow automated controlof flow to the incinerator assembly 550 and/or the vent assembly 570, toproduce outputs related to status of flow, status of components or thelike, as described herein.

Although the interface assembly 540 is described below as includingcertain components and functionality, in other embodiments an interfaceassembly can include only a portion of the components and functionalityas described with respect to the flow interface assembly 540.

The incinerator assembly 550 is configured to combust at least a portionof the fluid extracted from the gas well GW. The incinerator assembly550 can be coupled to the transportation platform 502, as shown in FIG.7. In other embodiments, however, the incinerator assembly 550 can bedisposed apart from the transportation platform 502, can be removably(or modularly) coupled to the transportation platform 502, or the like.The incinerator assembly 550 includes an incinerator intake valve 551,two pressure sensors 504, a temperature sensor 506, a flame arrestor515, an inlet member 552, and an incinerator 553. The incinerator valve551 can be similar in configuration to the first valve 516 and/or thesecond valve 517 described above with reference to the gas well adapter510. The incinerator valve 551 is configured to fluidically isolate theincinerator 553 and the outlet member 542 of the interface assembly 540in response to an event or condition.

The incinerator 553 is coupled to the first outlet 542 of the interfaceassembly 540 via the inlet member 552. The inlet member 552 can includeany suitable pipe, the two pressure sensors 504, the temperature sensor506, and the flame arrestor 515. The two pressure sensors 504, thetemperature sensor 506, and the flame arrestor 515 operate similarly tothe corresponding components described above within the gas well adapter510. The incinerator 553 can be any suitable incinerator configured tocombust the gas extracted from gas well GW. In some embodiments, theincinerator can be sized to combust fluids at flow rates of less than3000 CFM. In some embodiments, the incinerator 553 can be configured tocombust fluids having a methane gas concentration of between 15 percentand 100 percent. In some other embodiments the incinerator 553 can beconfigured to combust fluids at flow rates of between about 250 CFM andabout 2500 CFM.

The incinerator 553 includes sensors configured to monitor theperformance of the incinerator 553 and the characteristics of thecombustion within the incinerator 553. Specifically, in someembodiments, the incinerator 553 can include at least one thermocoupleconfigured and/or positioned to monitor combustion performance. In someembodiments, incinerator 553 can include emissions measurement sensorsto measure exhaust emissions (e.g., constituent concentration) to verifyefficiency of combustion and/or to verify the amount of methane (orother constituents within the extracted gas) destroyed.

Portions of the incinerator assembly 550, including the sensorsmonitoring the incinerator 553 described above, can be operably coupledto the control assembly 590. More particularly, portions of theincinerator assembly 550 can be operably coupled to system controller597 to allow automated control of the incinerator 553, to produceoutputs related to status of flow, status of components or the like, asdescribed herein.

The vent assembly 570 is configured to allow fluid extracted from thegas well GW to vent to the atmosphere with being combusted and/or routedthrough the incinerator assembly 550. Specifically, the vent assembly570 is configured to allow extracted gas to vent to atmosphere withoutbeing combusted when conditions for combustion within the incineratorassembly 550 are not suitable. The vent assembly 570, which is spacedapart from the incinerator 550 and/or the transportation platform 502,includes a vent 571, a vent valve 572, a pressure governor 574, twopressure sensors 504, a temperature sensor 506, a flame arrestor 515,and an inlet member 576. The vent valve 572 can be similar inconfiguration to the first valve 516 and/or the second valve 517. Thevent valve 572 is configured to stop the flow of extracted gas to thevent 571 in response to an event or condition.

The vent 571 is coupled to the second outlet 543 of the interfaceassembly 540 via the inlet member 576. The inlet member 576 can includeany suitable pipe, the two pressure sensors 504, the temperature sensor506, and the flame arrestor 515. The two pressure sensors 504, thetemperature sensor 506, and the flame arrestor 515 operate similarly tothe corresponding components described above within the gas well adapter510.

Portions of the vent assembly 570, including the sensors monitoring thevent 571 described above, can be operably coupled to the controlassembly 590. More particularly, portions of the vent assembly 570 canbe operably coupled to system controller 597 to allow automated controlof the vent assembly 570, to produce outputs related to status of flow,status of components or the like, as described herein.

FIG. 8 is a system block diagram of the control assembly 590. Thecontrol assembly 590 can be configured to interconnect the assemblieswithin system 500; monitor at least a portion of each of the assemblies;control various components of each of the assemblies; calculate variousdata based on monitored data, received data, and/or a combination ofmonitored and/or received data; receive local and/or remote commands;and communicate data. The control assembly 590 can be coupled to thetransportation platform 502. In other embodiments, however, the controlassembly 590 can be disposed apart from the transportation platform 502,can be removably/modularly coupled to the transportation platform 502,or the like. Although the control assembly 590 is described below asincluding certain components and functionality, in other embodiments, acontrol assembly can include only a portion of the components andfunctionality as described with respect to the control assembly 590.

The control assembly 590 is operably coupled to each of the gas welladapter 510, the extraction assembly 530, the interface assembly 540,the incinerator assembly 550, and the vent assembly 570. The controlassembly includes multiple systems interconnected to perform thefunctions described herein, including a measuring and monitoring system591, a communication system 592 in communication with a communicationstower (not shown in FIG. 7), a data storage and reporting system 595,and a system controller 597. Each of the systems of the control assembly590 can send signals to and receive signals from different assemblies ofthe system 500 depending on the function of the control system. FIGS.9-11 depict block diagrams showing signal paths of the various controlsystems of the control assembly 590. Specifically, FIG. 9 depictscontrol signal paths, FIG. 10 depicts monitoring and measuring signalpaths, and FIG. 11 depicts communication signal paths.

FIG. 9 is a block diagram showing the control signals A that can bereceived and/or produced by the system controller 597. The systemcontroller 597 can produce and transmit control signals to variousvalves described above (e.g., the first valve 516, the second valve 517,the incinerator valve 551, and/or the vent valve 572, etc). The systemcontroller 597 can also receive input from any of the sensors shown anddescribed herein (described in more detail below with respect to FIG.10). Moreover, the system controller 597 can also receive input from auser via the communication system 592 (manual override, etc.) and/orfrom a remote station via the communications tower 593. In this manner,a user can start, stop, and/or otherwise operate the system 500 eitherlocally and/or remotely. The system controller 597 includes one or moreprocessors configured to execute various control algorithms to ensurethe desired operation of the 500 (including safety shutdowns,adjustments to ensure integrity of the regulatory compliance report,environmental attribute credit (e.g., carbon offset credit) calculationor the like). Details of various control algorithms are discussed below.

FIG. 10 is a block diagram showing the measuring and monitoring signalsB that can be received and/or produced by the control assembly 590,specifically, by the monitoring and measurement system 591. Themonitoring and measurement system 591 receives signals from any of thesensors described above (pressure, temperature, concentration, etc);resulting from the calculations of individual monitoring component(e.g., methane concentration, flow rate calculation, greenhouse gasreduction, and/or efficiency, etc.); and/or from any component of any ofthe assemblies of the system 500 (e.g., feedback regarding a valveposition or the like). The monitoring and measurement system 591 canforward and/or adjust (e.g., perform calculations on) the data, receivedto the system controller 597 and/or the communications system 592. Thesystem controller 597 can use the monitoring and measurement data toproduce control signals to send to the components of the system 500, asdescribed herein. The communications system 592 can transmit measuringand monitoring data to a remote location for analysis and or storage.

FIG. 11 is a block diagram showing the communications signals C that canbe received and/or transmitted by the communications system 592. Thecommunications system can send and/or receive signals representing datato and/or from the system controller 597, monitoring and measurementsystem 591, data storage and reporting system 595 and/or the remotestation, as described herein. In this manner, the communication system592 can facilitate the transmission of data between the various systemswithin the control assembly 590, between the remote station and thesystem 500, and amongst the assemblies of the system 500 and the controlassembly 590.

As described above, the power source 531 can supply all of the power tothe system 500. Thus, the system 500 can be decoupled and/or can operateindependently from any external power source (electric power grid,portable generator set, or the like). FIG. 12 is a block diagram showingthe power transmission from the power source 532 to other componentswithin the system 500. As shown in FIG. 12, the power source 532supplies power to the gas well adapter 510, the interface assembly 540,the incinerator assembly 550, and the control systems of the controlassembly 590. In some embodiments, power source 532 can supply power toan electric motor or other device to drive the fluid machine 531. Insome embodiments, the power source 532 can supply power to componentsnot directly coupled to or disposed on the transportation platform 502,such as, for example, the vent assembly 570. Said another way, the powersource 532 can supply all of the power necessary to operate the system500. In this manner, the system 500 can operate, without the need forexternal fuel and/or electricity. While not shown in FIG. 7, 8, or 12,the system 500 can include any necessary converters (AC/DC, voltagedividers, etc.), transformers, or any other electrical system componentsto condition the power produced by the power source 532 to operate thecomponents of system 500 described herein.

Each component of the system 500 can be selected to correspond and/or becompatible with each of the other components within the system 500. Inparticular, the fluid handling components of the system 500 (e.g., thepiping, the valves, the flame arrestors and the like, described above)can be configured such that the operational characteristics of eachcomponent corresponds to and/or is compatible with the operationalcharacteristics of the other components. Such operationalcharacteristics include, for example, the range of flow rates and/orfluid pressure that each component is configured to receive and/orproduce. In this manner, the components can be “matched” or “dynamicallybalanced” to provide the desired overall system performance whilemaintaining the size, weight and portability characteristics describedherein. For example, the flame arrestors described herein are sized tooperate in the range of flow rates specified herein without producing ahigh frictional loss that could undesirably impact the performance ofthe fluid handling components downstream. Similarly, the fluid machine531 is configured to produce a substantially steady flow within theranges specified above without entering into regions of stall orunsteady performance. As another example, in embodiments in which thefluid machine 531 is configured to operate effectively from between 250CFM and 2500 CFM, the flame arrestors 515 are configured to operateeffectively from between 250 CFM and 2500 CFM without produce a highfrictional loss.

FIG. 13-FIG. 16 are flow charts depicting methods of operating thesystem 500 or any of the other systems described herein (e.g., thesystem 300 or the system 600). For any method described herein, any stepperformed can be manually performed by a local or remote user,automatically performed by a local or remote control system, and/or by acombination of local and/or remote manual and/or automated steps. Inthis manner, in any method of operating system 500, when the controlassembly, system controller, or other automated or automation componentperforms an action, a method may alternatively include alerting a userto perform the action. Similarly, when the control assembly, systemcontroller, or other automated or automation component does not performan action, a method may alternatively include alerting a user to notperform the action. Additionally, any method can repeat steps during theoperation of the system 500 to monitor the system 500, and/or to ensurethe continued operation of system 500.

FIG. 13 is a flow chart depicting a method 5000 operating the system500, specifically, a method of starting (i.e., allowing extracted gasflow through) the gas well adapter 510. Method 5000 includes checkingthe gas well pressure, at 5002, and determining whether the gas wellpressure is acceptable, at 5004. If the gas well pressure is notacceptable (e.g., above or below a predetermined range), controlassembly 590 does not open the gas well valve, the first valve 516and/or the second valve 517, at 5006. If the gas well pressure isacceptable (e.g., within a predetermined range), the gas well adapterstart is initiated, at 5008.

The method 5000 also includes de-energizing the gas well valve, thefirst valve 516 and/or the second valve 517 in response to certainmeasured conditions. In this manner, for example, the outlet member 513of the gas well adapter 510 can be fluidically isolated from the inletmember 512 of the gas well adapter 510 when conditions are not suitablefor system operation. The method includes determining whether thetemperature of the flame arrestor of the gas well adapter 510 is high,at 5010; whether the float switch is high, at 5012; and whether thesystem controller 597 maintains a “run” control signal, at 5014. If thetemperature of the flamer arrestor is high, the float switch is high(e.g., a switch indicating a level of condensation or other moistureaccumulation within the system), and/or the system controller 597 stopsthe “run” control signal, an actuator configured to open and close a gaswell adapter valve (e.g., the first valve 516 or the second valve 517)can close the gas well adapter valve if it is open, or maintain the gaswell adapter valve in its closed position, at 5016. If the temperatureof the flamer arrestor is low, the float switch is low, and/or thesystem controller 597 maintains the “run” control signal, an actuatorconfigured to open and close a gas well adapter valve can open the gaswell adapter valve if it is closed, at 5018. In some embodiments, suchas for example, if the first valve 516 is an isolation valve, and thesecond valve 516 is a non-return valve, the actuator with open and/orclose the first valve 516 in steps 5016 and 5018.

The method 5000 includes determining whether the gas well adapter valveproving switch is open, at 5020. If a valve proving switch is open orclosed, the control assembly 590 can receive a signal confirming that avalve is open or closed respectively. If the gas well adapter provingswitch is not open, the control assembly 590 trips the system 500, at5022, as will be described herein. The method 5000 also includesdetermining whether the gas well GW is under a vacuum, at 5024. If thegas well GW is under vacuum, a gas well adapter non-return valve can beactuated to prevent flow from the system 500 back into the gas well GW,at 5026. If the gas well GW is not under vacuum, fluid from gas well GWcan flows into the gas well adapter 510, at 5028. The method 500includes determining whether the temperature of the flame arrestor 515of the gas well adapter 510 is high, at 5030. If the temperature of theflame arrestor 515 of the gas well adapter 510 is high, the controlassembly 590 trips the system 500, at 5022. If the temperature of theflame arrestor 515 of the gas well adapter 510 is not high, fluid fromthe gas well GW is permitted to flow through the gas well adapter 510and into the fluid machine (e.g., fluid machine 531), at 5032.

The method 5000 can include an emergency stop sequence, at 5034. If anemergency stop is initiated, the control assembly 590 trips the system500, at 5022. If the control assembly trips the system 500, an actuatorcan close the gas well adapter valve, at 5036, and can determine thatthe gas well adapter valve proving switches are closed, at 5038. Whenthe gas well adapter valve proving switches are not closed, the method5000 includes sending an alarm, at 5040. When the gas well adapter valveproving switches are closed, the method 5000 includes shutting thesystem 500 down, at 5042.

FIG. 14 is a flow chart depicting a method 6000 operating the system500, and more specifically, a method of running the gas well adapter 510after the “start-up” period. The method 6000 includes determiningwhether the system controller 597 maintains a “run” control signal, at6002; whether the vent valve 572 proving switch is closed, at 6004;whether the temperature of the flamer arrestor 515 of the gas welladapter 510 is high, at 6006; whether the gas well adapter pipelinepressure is high, at 6008; whether the gas well adapter pipelinepressure is low, at 6010; whether the pressure switch is on, at 6012;and/or whether the water level is high, at 6014. The water level can beassociated with a level of condensation and/or water accumulation withinthe system. When the system controller 597 does not maintain a “run”control signal and/or sends a “stop” signal, the vent valve 572 provingswitch is open, the temperature of the flamer arrestor 515 of the gaswell adapter 510 is high, the gas well adapter pipeline pressure ishigh, the gas well adapter pipeline pressure is low, the pressure switchis off, and/or the water level is high, the control assembly 590 tripsthe system 500, at 6016, as described herein. When the system controller597 maintains a “run” control signal, the vent valve 572 proving switchis closed, the temperature of the flamer arrestor 515 of the gas welladapter 510 is not high, the gas well adapter pipeline pressure is nothigh, the gas well adapter pipeline pressure is not low, the pressureswitch is on, and the water level is not high, the method 6000 includesdetermining the pressure loss across a system filter, at 6018. Thefilter can be at any location within the system 500, such as, forexample, at the inlet to the power source 532 and/or at the inlet to thefluid machine 531.

The method 6000 includes determining if the pressure loss across thesystem filter is high (e.g., the pressure differential between apressure sensor upstream of the filter and a pressure sensor downstreamof the filter is high), at 6020. If the pressure differential is high,the system 500 can perform a manual or automatic emergency stop, at6022, and the control assembly 590 trips the system 500, at 6016. If thepressure differential is not high, the method 6000 includes checking thepressure loss across the flame arrestor 515 of the gas well adapter 510,at 5024. If the pressure loss is high, the system 500 can perform amanual or automatic emergency stop, at 6022; and if the pressure loss isnot high, the system can continue to run.

The method 6000 can include an emergency stop sequence, at 6028. If anemergency stop is initiated, the control assembly 590 trips the system500, at 6016. If the control assembly trips the system 500, an actuatorcan close the gas well adapter valve, at 6030, and can determine thatthe gas well adapter valve proving switches are closed, at 6032. Whenthe gas well adapter valve proving switches are not closed, the method6000 includes sending an alarm, at 6034. When the gas well adapter valveproving switches are closed, the method 6000 includes shutting thesystem 500 down, at 6036.

FIG. 15 is a flow chart depicting a method 7000 operating the system500, specifically, a method of “starting” the interface assembly 540,including starting the incinerator assembly 550 and/or diverting theextracted gas flow to the venting assembly 570. The method 7000 includesstarting the power source 532 and the fluid machine 531 with propane, at7002. In some embodiments, for example, the system 500 can include astarter fuel supply similar to the starter fuel supply 2 shown anddescribed above with reference to system 300. When the power source 532is not started on propane, the methane override timer is initiated, at7004. The methane override timer produces indication of a time periodduring which the system is not within certain operating conditions. Whenthe indicated time period exceeds a predetermined value, the system canbe shut down, in any manner described herein.

When the power source is started on propane, fluid flowing into thesystem (e.g., via the gas well adapter 510), at 7006. The method 7000then includes determining whether the methane concentration of theextracted gas from the gas well GW is less than twenty-five percent, at7008. If the methane concentration of the fluid is less than twenty-fivepercent, the method 7000 includes determining whether the methaneoverride timer is running, at 7010. If the methane override timer is notrunning, the control assembly 590 trips the system 500, at 7012, asdescribed herein. In this manner, when the methane concentration isbelow a rich flammability limit (i.e., is a combustible mixture) formore than a predetermined amount of time, the control assembly willprevent the operation of the system.

If the methane override timer is running and/or if the methaneconcentration of the fluid is greater than or equal to twenty-fivepercent, the method 7000 includes determining whether the vent valveproving switches are closed, at 7014; whether the flame-on vent sensoris showing the presence of a flame; whether the gas pressure within thesystem is high, at 7018; whether the gas pressure within the system islow, at 7020; and/or whether the temperature of the flame arrestor 515of the vent assembly 570 is high, at 7022. If the vent valve provingswitches are closed, the flame-on vent sensor indicates the presence ofa flame, the system pressure is either too high or to low, and/or thetemperature of the flame arrestor 515 of the vent assembly 570 is high,the control assembly 590 trips the system 500, at 7012.

If, however, the vent valve proving switches are open, the flame-on ventsensor is not showing the presence of a flame, there is not high systempressure, there is not low pressure, and the temperature of the flamearrestor 515 of the vent assembly 570 is not high, the method 7000includes the lifting the pressure governor 574 lifting to allow fluid toflow into the vent assembly 570, at 7024, which allows the extracted gasto vent to the atmosphere, at 7026. The method 7000 can includeinitiating the vent period incinerator purge timer, at 7028. The controlassembly can monitor the vent period incinerator purge timer todetermine if the incinerator starts operating within a predeterminedperiod of time after venting starts. If the incinerator does not startwithin the predetermined time the control assembly 590 trips the system500, at 7012. The method 7000 includes determining whether the ventperiod incinerator purge timer is running, at 7030. If the timer is nolonger running, venting continues, at 6032, and the vent assembly 570 isindicated as “running,” at 7034. If the timer is running, the interfaceassembly 540 directs fluid to the incinerator assembly, at 7036.

The method 7000 then includes starting the incinerator 553, at 7038, anddetermining whether the incinerator successfully started. If theincinerator 553 did not successfully start, the method 7000 returns tostep 7032. If the incinerator successfully starts, the method 7000includes monitoring the pressure within the incinerator 553. The method7000 includes determining whether the pressure within the incinerator553 has dropped, at 7040. A drop in incinerator 533 pressure canindicate that the incinerator 553 is not operating at maximum capacityand/or efficiency, and can require the venting process to stop tomaximize the efficiency and/or capacity of the incineration operation.The method 7000 includes closing the vent pressure governor 574, at7042, to stop the venting operation, at 7044. The method 7000 includescontinuing the incineration and/or restarting the incinerator 553 (e.g.,in the event that the pressure drop in step 7040 stopped the incinerator553), at 7046. The method 7000 includes the incinerator assemblyrunning, at 7048.

The method 7000 can include an emergency stop sequence, at 7050. If anemergency stop is initiated, the control assembly 590 trips the system500, at 7012. If the control assembly trips the system 500, an actuatorcan close the gas well adapter valve, at 7052, and can determine thatthe gas well adapter valve proving switches are closed, at 7054. Whenthe gas well adapter valve proving switches are not closed, the method5000 includes sending an alarm, at 7056. When the gas well adapter valveproving switches are closed, the method 5000 includes shutting thesystem 500 down, at 7058.

FIG. 16 is a flow chart depicting a method 8000 operating the system500, specifically, a method of running the interface assembly 540,including running the incinerator assembly 550 and the venting assembly570. The method 8000 includes determining whether the system controller587 is maintaining a “run” signal associated with the system 500, at8002. If the system controller 587 is no longer maintaining a “run”signal, and/or is sending a “stop” signal, the control assembly 590 cantrip the system 500, at 8004, as described herein. If the systemcontroller 587 is maintaining a “run” signal for the system 500, themethod 8000 includes determining whether the incinerator has tripped, at8006. If the incinerator 553 has tripped, the pressure relief valve ofthe incinerator 553 lifts, at 8008, and allows fluid within theincinerator to vent to the atmosphere, at 8010. After the incinerator553 has been reset, the system 500 can continue to run withincineration, at 8016. If the incinerator did not trip at 8006, themethod 8000 includes the system 500 running with incineration, at 8014.

The method 8000 includes determining whether the valve of the gas welladapter 510 is closed, at 8016; whether the methane concentration isgreater than twenty-five percent, at 8018; whether the gas pressure ishigh, at 8020; whether the gas pressure is low, at 8022; whether thetemperature of the flame arrestor 515 of the vent assembly 570 is high,at 8024; and/or whether the temperature of the incinerator is high, at8026. When the valve of the gas well adapter 510 is open, the methaneconcentration is less than twenty-five percent, the gas pressure ishigh, the gas pressure is low, the temperature of the flame arrestor 515of the vent assembly 570 is high, and/or whether the temperature of theincinerator is high, the control assembly 590 can trip the system 500,at 8004. When the valve of the gas well adapter 510 is closed, themethane concentration is greater than or equal to twenty-five percent,the gas pressure is not high, the gas pressure is not low, thetemperature of the flame arrestor 515 of the vent assembly 570 is nothigh, and whether the temperature of the incinerator is not high, thesystem 500 can continue to run, at 8028.

If an emergency stop is initiated, the control assembly 590 trips thesystem 500, at 8030. If the control assembly trips the system 500, anactuator can close the gas well adapter valve, at 8032, and candetermine that the gas well adapter valve proving switches are closed,at 80342. When the gas well adapter valve proving switches are notclosed, the method 5000 includes sending an alarm, at 8036. When the gaswell adapter valve proving switches are closed, the method 5000 includesshutting the system 500 down, at 8038.

As described herein, in some embodiments, the control system 590 cangenerate an output associated with a reduction in greenhouse gasemissions resulting from the combustion of the extracted gas. Moreover,in some embodiments, the control system 590 can generate environmentalattribute credits (e.g., carbon offset credits), which can be traded ona suitable exchange, based on the quantity of methane extracted andoxidized by the gas incinerator. The reduction in greenhouse gasemissions can be calculated based on the quantity of gas sent to theincinerator assembly 550, the concentration of certain constituentswithin the gas sent to the incinerator assembly 550 (e.g., the methaneconcentration), the operating temperature of the incinerator assembly550, combustion effectiveness (efficiency) of the incinerator assembly550, the runtime of power source 532 and/or the performancespecifications of the power source 532 (i.e., to calculate the amount ofmethane combusted by the power source). In particular, the power source532 reduces greenhouse gas emissions through the internal combustionprocess. The associated GHG emission reductions are calculated based onperformance specifications of the engine (e.g., BTU/HP-Hr, HP, runtime).

The extracted gas is continuously analyzed to determine the quantity ofgreenhouse gas (e.g., methane) that is processed by the system. Thesystem 500 controls the flow of gas to either the incinerator assembly550 or ventilation assembly 570, as described above. Gas that is sent tothe incinerator assembly 550 is combusted and converted into a gas witha lower global warming potential, as described above (e.g., CH4+O2converted into CO2+H2O). The combustion effectiveness (efficiency) ofthe incinerator is determined based on the incinerator design andoperating temperature of the incinerator. Gas that is sent to theventilation assembly 570 is not combusted or destroyed and thereforedoes not count towards GHG emission reductions.

FIGS. 17-20 show an integrated, self-contained methane extraction,incineration and monitoring system 600. FIG. 17 depicts the system 600in the first configuration, and FIGS. 18-20 depict the system 600 in thesecond configuration. The system 600 is similar to and can have similarcomponents to the system 500. Accordingly, similar components canperform similar functions. By way of example, fluid machine 631 of thesystem 600 can be similar in configuration to the fluid machine 531 ofthe system 500. Furthermore, any component described in relation tosystem 500, can be included in the system 600 and vice-versa. By way ofexample, the system 600 can have a vent assembly 670 (not shown in FIGS.17-20). Similarly, any component described in relation to system 600,can be included in the system 500. By way of example, the system 500 caninclude a support 605 (not shown in FIG. 7).

The system 600 includes a transportation platform 602 (having at leastone wheel 603 and a support 605), a fluid machine 631, a power source632, an incinerator 653, a control assembly 690, and an antenna tower694. The system is 600 is configured to extract methane gas; utilizemethane gas to produce mechanical, electrical, and/or heat energy;incinerate methane gas; vent methane gas to the atmosphere; reducepollutant constituents; and/or monitor and/or otherwise track thereduction of pollutant constituents, as described herein.

The system 600 can be moved between a first (or transportation)configuration (FIG. 17) and a second (or operational) configuration(FIGS. 18-20). More particularly, as shown, the incinerator 653 ismovably coupled to the transportation platform 602. When the incinerator653 is in a first position (corresponding to the first configuration ofthe system 600), a centerline CL of an exhaust stack of the incinerator653 is substantially parallel with a surface of the transportationplatform 602. In other embodiments, however, the centerline CL of theexhaust stack can form any suitable angle with the surface of thetransportation platform 602 (e.g., 10 degrees, 20 degrees, 45 degrees,or the like.) Moreover, when the incinerator 653 is in the firstposition, a vertical height of the incinerator 653 and thetransportation platform 602 is within a standard for on-roadtransportation, rail transportation and/or marine transportation. Suchstandards can include, for example, a state standard for size and/orweight of trailers for on-road transportation. In some embodiments, forexample, the when the incinerator 653 is in the first position, thevertical height of the incinerator 653 and the transportation platform602 can be less than 13 feet; 13 feet, six inches; 14 feet; 15 feet; or16 feet.

Similarly, the antenna tower 694 is movably coupled to thetransportation platform 602. When the antenna tower 694 is in a firstposition (corresponding to the first configuration of the system 600), acenterline (not identified in FIGS. 17-20) of an antenna tower 694 isconfigured to be substantially parallel with a surface of thetransportation platform 602. Moreover, when the antenna tower 694 is inthe first position, a vertical height of the antenna tower 694 and thetransportation platform 602 is within a standard for on-roadtransportation, rail transportation and/or marine transportation.

When the incinerator 653 is in a second position (corresponding to thesecond configuration of the system 600), the centerline CL of theexhaust stack of the incinerator 653 is substantially non-parallel witha surface of the transportation platform 602. More particularly, thecenterline CL of the exhaust stack of the incinerator 653 issubstantially normal to a surface of the transportation platform 602.Moreover, when the incinerator 653 is in the second position, a verticalheight of the incinerator 653 and the transportation platform 602 canexceed a standard for on-road transportation.

When the antenna tower 694 is in a second position (corresponding to thesecond configuration of the system 600), the centerline of the antennatower 694 is substantially non-parallel with a surface of thetransportation platform 602. More particularly, the centerline of theantenna tower 694 is substantially normal to a surface of thetransportation platform 602. Moreover, when the antenna tower 694 is inthe second position, a vertical height of the antenna tower 694 canexceed a standard for on-road transportation.

The incinerator 653 includes an actuator 656 to move the incineratorfrom its first position to its second position while the incinerator 653remains coupled to the transportation platform 602. Although shown asbeing a hydraulic actuator, in other embodiments, the actuator 653 canbe any suitable actuator (e.g., electric, pneumatic, etc). Theincinerator 653 also includes a support 655 to support the incineratorin the second configuration. The antenna tower 694 can be moved from itsfirst position to its second position manually, and or with an actuator(not shown).

As shown in FIGS. 17-20, when the system 600 is in the secondconfiguration, the incinerator 653 can be operably coupled to the fluidmachine 631 via an interface assembly (see e.g., FIG. 20) and a firstoutlet member 642. The vent assembly (not shown) can be operably coupledto the fluid machine 631 via the interface assembly (see e.g., FIG. 20)and a second outlet member 643.

While various embodiments have been described above, it should beunderstood that they have been presented by way of example only, notlimitation, and various changes in form and details may be made. Anyportion of the systems, apparatus and/or methods described herein may becombined in any combination, except mutually exclusive combinations. Theembodiments described herein can include various combinations and/orsub-combinations of the functions, components and/or features of thedifferent embodiments described.

For example, although the gas extraction systems have been shown anddescribed above as being used primarily in mining applications, in someembodiments, any of the systems shown and described above can be used toextract, combust and/or produce an indication of greenhouse gasemissions reduction from any source of gas. Such sources can includesources of gas associated with both active extraction (typicallyassociated with a mining environment) and passive venting (typicallyassociated with a gas and/or geological exploration operation). Moreparticularly, such sources can include gob wells or other extractionwells associated with a mining operation, landfill vents, gas wellsassociated with gas or geological exploration or the like.

Similarly, although the description above specifically refers to themining operation as being a coal mine, in other embodiments, the systemsdescribed herein can be used in conjunction with any mine. For example,in some embodiments, any of the system shown and described above can beused in conjunction with hard rock, metal and non-metal mines, such as,for example, trona mines.

Although the systems are described above as being used primarily tocombust hydrocarbons, and more particularly methane gas, any of thesystems described herein can be used to combust and/or measure thecombustion of any suitable gas constituents in the extracted gas toeffectuate a reduction in emissions. Such gas constituents can include,for example, any hydrocarbon and/or any volatile organic compound.

Although the control system as shown and described above for system 200is shown as being located remotely from the gas pump and/or theincinerator, in other embodiments, a system can include a control systemthat is located on-site (i.e., adjacent or in close proximity to the gaspump and/or the incinerator). For example, in some embodiments, a systemcan include a control system that is housed within the same trailer asthe remaining components of the system.

For example, apparatus, systems, and methods discussed in relation toone gas extraction, incineration, and monitoring system can beapplicable to any of the gas extraction, incineration, and monitoringsystems shown and described herein. Furthermore, each feature disclosedin this specification may be replaced by alternative features servingthe same, equivalent or similar purpose, unless expressly statedotherwise. Thus, unless expressly stated otherwise, each featuredisclosed is one example only of a generic series of equivalent orsimilar features.

Although the systems are described herein as being applicable for thecombustion of methane gas, the systems described herein can be used inconjunction with any suitable gas flow. Such gas flows can include gasflows including any type of flammable gas, any type of greenhouse gas, amixture of flammable gas and air, or a mixture of flammable gas andinert elements (or inerts) such as nitrogen or carbon dioxide.

Although fluid concentration sensor 508 is shown as being disposedwithin the inlet member 541 of the interface assembly 540, in someembodiments, the gas concentration sensor and associated instrumentationcan be included within the measuring and monitoring system 591 of thecontrol assembly 590. In such embodiments, the inlet member 541 caninclude a supply line and/or instrumentation tap through which a sampleportion of the gas flow can be conveyed to the measuring and monitoringsystem.

In some embodiments, an incinerator, such as incinerator 653 can includea fan or fluid machine therein configured to increase the combustionperformance of the incinerator. In this manner, the overall height ofthe incinerator (i.e., the height taken along the centerline CL) can bemade small enough for the incinerator to fit onto the transportationplatform when in the first position. In some embodiments, for example,an incinerator can include a turbulence generator (e.g., fans,protrusions within the flow path or the like) to improve the combustionefficiency therein.

Although the system 600 is shown and described as including anincinerator 653 that is movably coupled to the transportation platform602, in other embodiments, the incinerator 653 can be removably coupledto the transportation platform 602.

1. An apparatus, comprising: a frame; an inlet member coupled to theframe, the inlet member configured to be coupled to a gas well; anoutlet member coupled to the frame, the outlet member configured to becoupled to a receiver configured to receive a gas flow from the gas wellwhen the inlet member is in fluid communication with the gas well; avalve configured to selectively place the inlet member in fluidcommunication with the outlet member; and an electrical isolation memberconfigured to electrically isolate the inlet member and the outletmember.
 2. The apparatus of claim 1, wherein the frame includes acoupling portion configured to removably couple the frame to atransportation platform.
 3. The apparatus of claim 1, wherein the inletmember includes a flexible portion configured to couple the inlet memberto an outlet pipe of the gas well, the outlet pipe forming an angle witha ground surface of between zero and ninety degrees.
 4. The apparatus ofclaim 1, further comprising: a controller configured to deactuate thevalve to fluidically isolate the inlet member from the outlet member inresponse to at least one of a signal associated with a pressure withinthe gas well, a signal associated with a temperature of a flamearrestor, a signal associated with a concentration of a constituent gaswithin the gas flow, and a signal associated with a status of a ventisolation valve.
 5. The apparatus of claim 1, further comprising: aflame arrestor disposed between inlet member and outlet member.
 6. Asystem, comprising: a transportation platform; a fluid machine coupledto the transportation platform, the fluid machine configured to becoupled to a gas well and to produce a gas flow from the gas well; anincinerator configured to be fluidically coupled to the fluid machine,the incinerator configured to combust at least a portion of the gas flowwhen the incinerator is fluidically coupled to the fluid machine; a ventassembly configured to be fluidically coupled to the fluid machine; anda flow interface assembly coupled to the transportation platform, theflow interface assembly configured to selectively place the fluidmachine in fluid communication with any one of the incinerator and thevent assembly.
 7. The system of claim 6, further comprising: a powersource operatively coupled to the fluid machine, the power sourceconfigured to produce power to operate the fluid machine from a portionof the gas flow produced by the fluid machine.
 8. The system of claim 6,wherein the incinerator is coupled to the transportation platform. 9.The system of claim 6, further comprising: a controller operativelycoupled to the flow interface assembly, the controller configured toactuate a valve to place the incinerator in fluid communication with thefluid machine in response to at least one of an amount of time that thevent assembly has been in fluid communication with the fluid machine, asignal associated with a concentration of a constituent gas within thegas flow, a signal associated with a pressure within the gas well, and asignal associated with a temperature of a flame arrestor.
 10. The systemof claim 6, further comprising: a controller operatively coupled to theflow interface assembly, the controller configured to actuate a valve toplace the incinerator in fluid communication with the fluid machine inresponse to a control signal, the controller is further configured toautomatically actuate the incinerator to combust the portion of the gasflow when the incinerator is in fluid communication with the fluidmachine.
 11. The system of claim 6, further comprising: a controlleroperatively coupled to the flow interface assembly, the controllerconfigured to receive a first signal associated with a rate of the gasflow to the incinerator and a second signal associated with aconcentration of a constituent gas within the gas flow, the controlleris further configured to receive a third signal associated with a statusof the incinerator, the controller is further configured to generate anoutput associated with a reduction in greenhouse gas emissions based, atleast in part, on the first signal, the second signal and the thirdsignal.
 12. The system of claim 6, further comprising: a gas welladapter disposed between the fluid machine and the gas well, the gaswell adapter configured to electrically isolate the gas well from thefluid machine.
 13. A system, comprising: a transportation platform; afluid machine coupled to the transportation platform, the fluid machineconfigured to be coupled to a gas well and to produce a gas flow fromthe gas well; an incinerator movably coupled to the transportationplatform between a first position and a second position, a verticalheight of the incinerator and the transportation platform is within astandard for on-road transportation when the incinerator is in the firstposition, the incinerator configured to be fluidically coupled to thefluid machine when the incinerator is in the second position, theincinerator configured to combust at least a portion of the gas flowwhen the incinerator is in the second position; and a flow interfaceassembly coupled to the transportation platform, the flow interfaceassembly configured to selectively place the fluid machine in fluidcommunication with any one of the incinerator and a vent assembly. 14.The system of claim 13, wherein the incinerator remains coupled to thetransportation platform when moved between the first position and thesecond position.
 15. The system of claim 13, wherein the vertical heightof the incinerator and the transportation platform exceeds the standardfor on-road transportation when the incinerator is in the secondposition.
 16. The system of claim 13, wherein the incinerator remainscoupled to the transportation platform when moved between the firstposition and the second position, a centerline of an exhaust stack ofthe incinerator configured to be substantially parallel with a surfaceof the transportation platform when the incinerator is in the firstposition, the center line of the exhaust stack configured to benon-parallel with the surface of the transportation platform when theincinerator is in the second position.
 17. The system of claim 13,further comprising: a controller configured to be operably coupled tothe flow interface assembly, the controller configured to actuate avalve to place the incinerator in fluid communication with the fluidmachine in response to at least one of an amount of time that the ventassembly has been in fluid communication with the fluid machine, asignal associated with a concentration of a constituent gas within thegas flow, a signal associated with a pressure within the gas well, and asignal associated with a temperature of a flame arrestor.
 18. The systemof claim 13, further comprising: a controller configured to be operablycoupled to the flow interface assembly, the controller configured toreceive a first signal associated with a rate of the gas flow to theincinerator and a second signal associated with a concentration of aconstituent gas within the gas flow, the controller is furtherconfigured to receive a third signal associated with a status of theincinerator, the controller is further configured to generate an outputassociated with a reduction in greenhouse gas emissions based, at leastin part, on the first signal, the second signal and the third signal.19. The system of claim 13, further comprising: a gas well adapterdisposed between the fluid machine and the gas well, the gas welladapter configured to electrically isolate the gas well from the fluidmachine.